Systems and methods for core flooding

ABSTRACT

A core flooding system includes a core holder that encloses a core sample of a subterranean formation. The core holder includes a fluid inlet and a fluid outlet; at least one sensor coupled to the core holder or positioned in the inner volume of the core holder; an acoustic vibrating assembly coupled to the core holder; and a control system communicably coupled to the at least one sensor and the acoustic vibrating assembly. The control system performs operations including operating the acoustic vibrating assembly to transmit at an acoustic wave energy or a vibration energy to the core holder; during the transmission of the at least one of the acoustic wave energy or the vibration energy to the core holder; measuring at least one parameter of the core sample; and based on the at least one measured parameter, determining at least one property of the core sample.

CROSS-REFERENCE TO RELATED APPLICATION

This application is a divisional of and claims the benefit of priorityto U.S. patent application Ser. No. 16/892,977, filed Jun. 4, 2020, theentire contents of which are incorporated by reference herein.

TECHNICAL FIELD

This disclosure relates to systems and method for core flooding and,more particularly, systems and methods for core flooding whilesubjecting a core sample to wave energy.

BACKGROUND

In the oil and gas industry, core holders are used mainly to simulateflooding experiments that can provide valuable measurements related tooil and gas recovery, fluid permeability, and flow properties. The coreflooding experiments are generally conducted at high pressure andtemperature representing reservoir conditions.

SUMMARY

This disclosure describes systems and methods for core flooding of acore sample in a core flooding system that includes, for example, one ormore sub-assemblies that generate and transmit vibration energy oracoustic wave energy (or both) to the core sample. In some aspects, theone or more sub-assemblies may generate and transmit such energydirectly to the core sample. In some aspects, the one or moresub-assemblies may generate and transmit such energy indirectly to thecore sample. Measurements of one or more parameters of the core samplemay be taken during such transmission of energy. The measuredparameter(s) may be used to determine one or more properties of the coresample, and consequently, a reservoir formation from which the coresample is taken.

In an example implementation, a core flooding system includes a coreholder that includes a housing that defines an inner volume sized toenclose a core sample of a subterranean formation, the core holderfurther including a fluid inlet and a fluid outlet; at least one sensorcoupled to the core holder or positioned in the inner volume of the coreholder; an acoustic vibrating assembly coupled to the core holder; and acontrol system communicably coupled to the at least one sensor and theacoustic vibrating assembly. The control system is configured to performoperations including operating the acoustic vibrating assembly totransmit at least one of an acoustic wave energy or a vibration energyto the core holder; during the transmission of the at least one of theacoustic wave energy or the vibration energy to the core holder;measuring at least one parameter of the core sample with the at leastone sensor; and based on the at least one measured parameter,determining at least one property of the core sample.

In an aspect combinable with the example implementation, the acousticvibrating assembly includes a mechanical vibrator mounted on a platform,the mechanical vibrator coupled to the core holder.

In another aspect combinable with any of the previous aspects, theplatform includes at least one rotating plate to which the core holderis mounted.

In another aspect combinable with any of the previous aspects, thecontrol system is configured to perform operations further includingoperating the at least one rotating plate to rotate the core holderabout an axis.

In another aspect combinable with any of the previous aspects, the axisincludes a first axis, the control system configured to performoperations further including operating the at least one rotating plateto rotate the core holder about a second axis.

In another aspect combinable with any of the previous aspects, operatingthe at least one rotating plate to rotate the core holder about thesecond axis is performed simultaneously with operating the at least onerotating plate to rotate the core holder about the first axis.

Another aspect combinable with any of the previous aspects furtherincludes at least one spring mounted to the mechanical vibrator.

In another aspect combinable with any of the previous aspects, theacoustic vibrating assembly includes at least one perforated rod thatincludes an airflow path; and at least one balloon fluidly coupled tothe airflow path through the perforated rod.

In another aspect combinable with any of the previous aspects, thecontrol system is configured to perform operations further includingflowing a gas through the airflow path to inflate the at least oneballoon to induce the vibration energy through the core holder.

Another aspect combinable with any of the previous aspects furtherincludes a sleeve mountable within the inner volume and sized to holdthe core sample, the acoustic vibrating assembly including a vibratormounted within the sleeve to impart the at least one of the acousticwave energy or the vibration energy to the core sample.

In another aspect combinable with any of the previous aspects, theacoustic vibrating assembly includes a noise source positionable apartfrom the core holder, the control system configured to performoperations further including operating the noise source to generate theacoustic wave energy.

Another aspect combinable with any of the previous aspects furtherincludes at least one valve fluidly coupled to at least one of the fluidinlet or the fluid outlet.

In another aspect combinable with any of the previous aspects, thecontrol system is configured to perform operations further includingoperating the at least one valve to flow a fluid through the innervolume of the core holder.

In another aspect combinable with any of the previous aspects, theoperation of operating the at least one valve to flow the fluid throughthe inner volume of the core holder occurs simultaneously with operatingthe acoustic vibrating assembly to transmit at least one of the acousticwave energy or the vibration energy to the core holder.

In another example implementation, a method for testing a core sampleincludes positioning a subterranean formation core sample in an innervolume of a core holder, the core holder including a housing thatdefines the inner volume, a fluid inlet, and a fluid outlet;transmitting at least one of an acoustic wave energy or a vibrationenergy to the core holder; during the transmission of the at least oneof the acoustic wave energy or the vibration energy to the core holder;measuring at least one parameter of the core sample with at least onesensor coupled to the core holder or positioned in the inner volume ofthe core holder; and based on the at least one measured parameter,determining at least one property of the core sample.

In an aspect combinable with the example implementation, transmitting atleast one of the acoustic wave energy or the vibration energy to thecore holder includes operating a mechanical vibrator coupled to the coreholder and mounted on a platform.

Another aspect combinable with any of the previous aspects furtherincludes rotating the core holder about an axis with at least onerotating plate to which the core holder is mounted.

In another aspect combinable with any of the previous aspects, the axisincludes a first axis, the method further including rotating the coreholder about a second axis with the at least one rotating plate.

In another aspect combinable with any of the previous aspects, rotatingthe core holder about the first and second axes occurs simultaneously.

In another aspect combinable with any of the previous aspects,transmitting at least one of the acoustic wave energy or the vibrationenergy to the core holder includes flowing a fluid through an airflowpath of at least one perforated rod coupled to the core holder;inflating at least one balloon fluidly coupled to the airflow paththrough the perforated rod; and based on inflating the at least oneballoon, transmitting at least one of the acoustic wave energy or thevibration energy to the core holder.

Another aspect combinable with any of the previous aspects furtherincludes, while transmitting at least one of the acoustic wave energy orthe vibration energy to the core holder, inflating at least one balloonmounted to the core holder; and based on inflating the at least oneballoon, tilting the core holder.

In another aspect combinable with any of the previous aspects,transmitting at least one of the acoustic wave energy or the vibrationenergy to the core holder includes vibrating the core sample with avibrator mounted to or within a sleeve that holds the core sample toimpart the at least one of the acoustic wave energy or the vibrationenergy to the core sample.

In another aspect combinable with any of the previous aspects,transmitting at least one of the acoustic wave energy or the vibrationenergy to the core holder includes generating the acoustic wave energywith a noise source positioned apart from the core holder.

Another aspect combinable with any of the previous aspects furtherincludes modulating at least one valve fluidly coupled to at least oneof the fluid inlet or the fluid outlet; and circulating a fluid throughthe inner volume of the core holder to contact the core sample.

In another example implementation, a core sample test apparatus includesa housing sized to receive a core sample that includes a portion of ahydrocarbon reservoir formation; means for generating at least one of anacoustic wave energy or a vibration energy to the core holder; at leastone sensor positioned to detect a change in at least one parameter ofthe core sample during operation of the means for generating the atleast one of the acoustic wave energy or the vibration energy; and acontrol system communicably coupled to the at least one sensor andconfigured to receive the change in the at least one parameter of thecore sample and determine at least one property of the hydrocarbonreservoir formation.

In an aspect combinable with the example implementation, the controlsystem is operably coupled to the means for generating.

Another aspect combinable with any of the previous aspects furtherincludes means for rotating the core sample.

In another aspect combinable with any of the previous aspects, thecontrol system is operably coupled to the means for rotating.

In another aspect combinable with any of the previous aspects, the atleast one parameter of the core sample includes at least one of a flowrate of a fluid through the core sample; an interfacial tension; acontact angle between a fluid and the core sample; a fluid path of wateror brine through the core sample; or a fluid path of a hydrocarbonthrough the core sample.

In another aspect combinable with any of the previous aspects, the atleast one property of the hydrocarbon reservoir formation a permeabilityof the hydrocarbon reservoir formation; a brine permeability of thehydrocarbon reservoir formation; or a porosity of the hydrocarbonreservoir formation.

In another aspect combinable with any of the previous aspects, thesensor includes a fiber optic conductor mounted within a sleeveconfigured to hold the core sample in the housing.

Implementations of a core flooding system according to the presentdisclosure may include one or more of the following features. Forexample, the core flooding system may monitor changes in an environmentin which a core sample is tested under vibration and seismicity effects.As another example, the core flooding system may more efficiently andprecisely monitor preferred paths of water, oil, and gases through acore sample under vibration and seismicity effects. As still a furtherexample, the core flooding system may provide a better estimation for apermeability continuous profile, which is not possible by conventionaltechniques, and compare this profile with the brine permeabilityresults. For example, the core flooding system may include one or moresensors to measure certain parameters, such as differential pressure ofeach phase of a multiphase fluid within (or flowing through) the coresample to evaluate a permeability profile of the core sample.

Implementations of a core flooding system according to the presentdisclosure may also include one or more of the following features. Forexample, the core flooding system may better assess future enhanced oilrecovery (EOR) processes, injectivity, and water shut off jobs ascompared to conventional techniques. As another example, the coreflooding system may better assess certain parameters (such asinterfacial tension and contact angle) that are helpful for hydrocarbonreserve evaluation and fluids distribution in oil and gas reservoirs ascompared to conventional techniques. Also, the core flooding system mayreduce an amount of time, money, and risk associated with suchcompletion techniques by providing more accurate reservoir information.As another example, the core flooding system may facilitate assessmentof parameters that allow evaluation of a fluid distributions in atransition zone, a remaining oil saturation post water flooding, and anadditional oil recovery as a result of an EOR injectant.

The details of one or more implementations of the subject matterdescribed in this disclosure are set forth in the accompanying drawingsand the description below. Other features, aspects, and advantages ofthe subject matter will become apparent from the description, thedrawings, and the claims.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is a side cross-section of a schematic diagram of an exampleimplementation of a core flooding system according to the presentdisclosure.

FIGS. 2A-2B are side and end views, respectfully, of another exampleimplementation of a core flooding system according to the presentdisclosure.

FIG. 3 is a flowchart that describes an example method performed with acore flooding system according to the present disclosure.

FIG. 4 is a schematic illustration of an example controller (or controlsystem) for controlling operations of a core flooding system accordingto the present disclosure

DETAILED DESCRIPTION

FIG. 1 is a side cross-section of a schematic diagram of an exampleimplementation of a core flooding system 100 according to the presentdisclosure. Generally, the core flooding system 100 may operate toanalyze a core sample 112, as well as a fluid flow through the coresample 112, under various and varying conditions, including a wide rangeof vibrational frequencies, acoustic wave energy, rotation and tilting,and convention varying conditions such as temperature and pressure. Insome aspects, the use of vibration to improve oil recovery has beenimplemented, with successful vibration stimulation in shallow reservoirswith high water-to-oil ratios (WOR). Laboratory and pre-pilotfield-testing of a vibration impact, for example, to simulate suchconditions, has been lacking. The core flooding system 100 implementssuch conditions using vibro-seismic technology that generatesvibrational energy, acoustic wave energy, or both.

As shown in this example implementation, the core flooding system 100includes a core holder 102 that is comprised of a housing 104 (forexample, a cylindrical housing) that may be enclosed on open ends by endplates 108 to define an inner volume 106. The core sample 112 may beinserted into the inner volume 106 (and enclosed there by the housing104 and the plates 108). In some aspects, as shown, a sleeve 110 (forexample, a flexible sleeve) may be used to hold the core sample 112 inthe inner volume 106.

In this example, a fluid inlet 114 is positioned through one end plate108 while a fluid outlet 116 is positioned through another end plate108. A fluid 120 (such as water, oil, gas, or a mixture thereof) may becirculated through the inner volume 106 and saturate or contact the coresample 112. As shown in this example, valves 118 may be positioned onboth of the inlet 114 and the outlet 116 to control a flow of the fluid120.

Like conventional core flooding systems, the core flooding system 100may conduct core flooding and interfacial tension contact angle teststhat mimic reservoir conditions (for example, pressure, temperature, andreservoir fluids). In some aspects, the core flooding system 100 mayapply a constant pressure across the end plates 108 or constant flowthrough the end plates 108 (or core plugs, not shown). Core flood testscan be conducted using single or multiple core holders to acquirecritical reservoir properties such as permeability contrasts and fluidmovement in porous media. Core flooding results may then be used toguide mathematical models and extract critical simulation parameters.While helpful, such conventional tests (which still may be performed bythe core flooding system 100), may not take into consideration an impactof natural or imposed seismic activities as well as surface vibrationsby heavy equipment. As explained more fully herein, the core floodingsystem 100 and other example implementations of a core flooding systemaccording to the present disclosure may generate vibration energy,acoustic energy, or both, and measure one or more parameters associatedwith the core sample 112 to determine one or more geologic properties ofthe core sample 112 or an associated reservoir formation.

For example, as shown in FIG. 1, an acoustic vibration assembly 122 maybe coupled to (for example, near, or in contact with) the core holder102. Generally, the acoustic vibration assembly 122 may include one ormore sub-assemblies that generate vibration energy, acoustic waveenergy, or both and transmit such energy 124 to the core holder 102 and,subsequently, the core sample 112. In some aspects, one or moresub-assemblies of the acoustic vibration assembly 122 may be in contactwith the core holder 102 and provide direct vibrational energy 124 tothe core holder 102. In some aspects, one or more sub-assemblies of theacoustic vibration assembly 122 may be spaced apart from (and not incontact with) the core holder 102 and provide remote acoustic waveenergy 124 to the core holder 102 and subsequently, the core sample 112.In some aspects, one or more sub-assemblies of the acoustic vibrationassembly 122 may not be in direct contact with the core holder 102, butmay provide direct vibrational energy to other components of the system100 that are in contact with the core holder 102 (thereby providingindirect vibrational energy 124 to the core holder 102, andsubsequently, the core sample 112).

As shown in this example, a rotation assembly 126 may also be coupled(directly or otherwise) to the core holder 102. The rotation assembly126 may be operated to rotate or tilt the core holder 102, such as withrotation 128. In some aspects, the rotation assembly 126 may be operatedto tilt or rotate the core holder 102 about an axis 136 (radial axis136) that is coincident with a centerline radial axis of the core sample112. In some aspects, the rotation assembly 126 may be operated to tiltor rotate the core holder 102 about an axis 138 (axial axis 138) that isorthogonal to the centerline radial axis 136 of the core sample 112. Insome aspects, the rotation assembly 126 may be operated to tilt orrotate the core holder 102 about an axis 140 (axial axis 140) that isorthogonal to the centerline radial axis 136 of the core sample 112 aswell as axis 138. In some aspects, the rotational assembly 126 may beoperated to rotate or tilt the core holder.

In some aspects, operation of the rotation assembly 126 and the acousticvibration assembly 122 may be simultaneous. In some aspects, operationof the rotation assembly 126 and the acoustic vibration assembly 122 maybe sequential. Further, in some aspects, changes in temperature,pressure, or both, within the inner volume 106 (and thus the core sample112) may be made in parallel with or sequentially with one or both ofthe rotation assembly 126 and the acoustic vibration assembly 122. Stillfurther, changes in properties of the fluid 120 (for example,composition, pressure, temperature, and otherwise) may be made inparallel with or sequentially with one or both of the rotation assembly126 and the acoustic vibration assembly 122, as well as in parallel withor sequentially with other conventional testing parameters (for example,temperature or pressure).

As shown in this example, the core flooding system 100 includes one ormore fluid sensors 130 (in this case, two), as well as other sensors 132and 134. In some aspects, each sensor shown in FIG. 1 may represent oneor multiple sensors. Each sensor shown in FIG. 1 may also be an analogor digital sensor. In some aspects, the illustrated sensors 130, 132,and 134 may be fiber optic conductors. As shown in this example, one ormore sensors 132 may be positioned within the internal volume 106 (butexternal to the sleeve 110). Further, in this example implementation,one or more sensors 134 may be positioned between the core sample 112and the sleeve 110. Alternatively, sensors may be placed external to(for example, in contact with an exterior surface of) the housing 104.

The example implementation of the core flooding system 100 includes acontrol system 999. In some implementations, the control system 999 is amicroprocessor-based control system that includes one or more hardwareprocessors, one or more memory modules communicably coupled to thehardware processor(s), and instructions and data encoded on the one ormore memory modules. The hardware processor(s) are operable to executethe instructions to perform operations, including operations describedin the present disclosure. As shown in this example (for example, by thebi-directional arrows), the control system 999 may be communicablycoupled (wired or wirelessly) to, for instance, the acoustic vibrationassembly 122, the sensors 130, 132, and 134, and the rotation assembly126. In some aspects, the control system 999 may receive data from theacoustic vibration assembly 122, the sensors 130, 132, and 134, and therotation assembly 126, as well as provide commands (pre-programmed orotherwise) to the acoustic vibration assembly 122, the sensors 130, 132,and 134, and the rotation assembly 126.

For example, in an example operation, the control system 999 may commandthe acoustic vibration assembly 122 to operate one or more acousticvibration sub-assemblies to generate and transmit the vibration and/oracoustic wave energy 124 to the core holder 102 (and thus the coresample 112). The control system 999 may also command the rotationassembly 126 to tilt or rotate the core holder 102 (and thus the coresample 112), either simultaneous with or sequentially with the operationof the acoustic vibration assembly 122. The control system 999 may alsocommand one or more valves 118 to facilitate circulation of the fluid120 into the inner volume 106 of the core holder 102 (and thus to thecore sample 112), either simultaneous with or sequentially with theoperation of the acoustic vibration assembly 122, the rotation assembly126, or both. Further, the control system 999 may operate to adjust atemperature or pressure within the inner volume 106. The sensors 130,132, and/or 134 may measure one or more parameters associated with thecore sample 112, such as temperatures, confining stresses, pressures,fluid content, directional flow (for example, velocity, pathways, orboth) of one or more phases of a multiphase fluid, and other parameters.In some aspects, for instance, movement (for instance, rotation,tilting, vibration) of the core holder 102 in different directions canaffect the evaluation of directional permeability, vertical permeability(such as in tilted reservoirs) and can evaluate gravity drainage effectson remaining oil saturation (SOR) and additional hydrocarbon recovery ina reservoir.

Based on such measurements, the control system 999 may determine one ormore properties of the core sample 112, and also a reservoir formationfrom which the core sample 112, was taken. Such properties include, forexample, porosity, grain density, directional permeability, and otherproperties. In some aspects, results of the determination of the one ormore properties may be presented to a user or operator of the coreflooding system 100 through a graphical user interface (GUI) of thecontrol system 999.

FIGS. 2A-2B are side and end views, respectfully, of another exampleimplementation of a core flooding system 200 according to the presentdisclosure. Generally, the core flooding system 200 may operate toanalyze a core sample 212, as well as a fluid flow through the coresample 212, under various and varying conditions, including a wide rangeof vibrational frequencies, acoustic wave energy, rotation and tilting,and convention varying conditions such as temperature and pressure. Insome aspects, the use of vibration to improve oil recovery has beenimplemented, with successful vibration stimulation in shallow reservoirswith high water oil ratios (WOR). Laboratory and pre-pilot field-testingof a vibration impact, for example, to simulate such conditions, hasbeen lacking. The core flooding system 200 implements such conditionsusing vibro-seismic technology that generates vibrational energy,acoustic wave energy, or both.

As shown in this example implementation, the core flooding system 200includes a core holder 202 that is comprised of a housing 204 (forexample, a cylindrical housing) that may be enclosed on open ends by endplates 208 (or core plugs 208) to define an inner volume 206. The coresample 212 may be inserted into the inner volume 206 (and enclosed thereby the housing 204 and the plates or plugs 208). In some aspects, asshown, a sleeve 210 (for example, a flexible sleeve) may be used to holdthe core sample 212 in the inner volume 206.

In this example, multiple fluid inlets 214 a, 214 b, and 214 c arepositioned through one end plate 208 while a fluid outlet 216 ispositioned through another end plate 208. In this example, a differentfluid 220 a, 220 b, and 220 c may be circulated through each respectiveinlet 214 a-214 c. For example, in some aspects, fluid 220 a may bewater, fluid 220 b may be oil, and fluid 220 c may be gas. The fluids220 a-220 c are circulated to the core sample 212, in which they may mixor flow there through in separate paths to be combined in an outletfluid 222. Although note shown in this example, one or more valves maybe positioned on one or both of the inlet 214 and the outlet 216 tocontrol a flow of the fluids 220 a-220 c and the outlet fluid 222. Thevalves, in some aspects, may be controlled by control system 999 shownin these figures.

Like conventional core flooding systems, the core flooding system 200may conduct core flooding and interfacial tension contact angle teststhat mimic reservoir conditions (for example, pressure, temperature, andreservoir fluids). In some aspects, the core flooding system 200 mayapply a constant pressure across the end plates 208 or constant flowthrough the end plates 208 (or core plugs 208). Core flood tests can beconducted using single or multiple core holders to acquire criticalreservoir properties such as permeability contrasts and fluid movementin porous media. Core flooding results may then be used to guidemathematical models and extract critical simulation parameters.

While helpful, such conventional tests (which still may be performed bythe core flooding system 200), may not take into consideration an impactof natural or imposed seismic activities as well as surface vibrationsby heavy equipment. As shown in FIGS. 2A-2B, the system 200 may includemultiple acoustic vibration sub-assemblies, each of which may beoperated to generate and transmit vibration and/or acoustic energy tothe core holder 202, either sequentially or together. For example,system 200 includes mechanical vibrator 224 that may be communicablycoupled to the control system 999. In some aspects, the mechanicalvibrator 224 may be operated (for example, by the control system 999) togenerate vibration energy 228 and transmit the generated vibrationenergy 228 to the core holder 202 (for example, directly to the coreholder 202 through direct contact). In some aspects, such directvibration energy transmitted by the mechanical vibrator 224 may mobilizeoil or other hydrocarbon fluid that is trapped (stationary) within thecore sample 212 during testing.

As shown in this example, a plate 226 may be mounted to the mechanicalvibrator 224 and operated (for example, by the control system 999) torotate about one or more axes (such as one or more of the axes in thex-y-z coordinate system 244 shown in FIG. 2A). The core holder 202 maybe coupled to the plate 226 during operation, thereby allowing forrotation of the core holder 202 and the core sample 212 during testing.In some aspects, as shown, one or more springs 237 may be positionedbetween the mechanical vibrator 224 and the plate 226 to transmit oreven enhance the vibration energy 228 provided to the core holder 202.

As shown in this example, system 200 includes another acoustic vibrationsub-assembly in the form of rods 230 that are mounted at axial ends ofthe core holder 202 as shown. In this example, each of the rods 230include an airflow path 232 (shown as an example on one of the rods 230)that, for instance, is internal to the rods 230. One or more balloons234 (two for each rod 230 in this example) are fluidly coupled to theairflow paths 232 of the rods 230, for example, through one or moreperforations in the rods 230. Airflow from an airflow source (not shown)may be circulated (for example, by the control system 999) through theairflow paths 232 to inflate the balloons 234 in order to induce adirect vibration energy on the core holder 202. For instance, bysequentially inflating and deflating the balloons 234 (and varying therelative inflation of each of the balloons), the direct vibration energy(for example, both axial and radial energy relative to the position ofthe core sample 212) may be generated and transmitted to the core holder202 and thus the core sample 212 during testing. In some aspects, suchdirect vibration energy transmitted by the balloons 234 may mobilize oilor other hydrocarbon fluid that is trapped (stationary) within the coresample 212 during testing.

As shown in this example, system 200 includes another acoustic vibrationsub-assembly in the form of an acoustic vibrator 235 that is positionedbetween the sleeve 210 and the core sample 212. In some aspects, theacoustic vibrator 235 may be operated (for example, by the controlsystem 999) to generate acoustic wave energy (for example,electromagnetic wave energy similar to EM logging tools) directly to thecore sample 212 during testing. In some aspects, such direct acousticwave energy transmitted by the acoustic vibrator 235 may act on aninterface of the different fluids or emulsion layer within the coresample 212 and separate suspended oil bubbles within water to helpmobilize trapped oil within the core sample 212 during testing.

As further shown in this example, system 200 includes another acousticvibration sub-assembly in the form of an acoustic noise source 238 thatis positioned remotely from (for example, not in direct contact with)the core holder 202. The acoustic noise source 238 may be operated (forexample, by the control system 999) to generate acoustic wave energy 239(for instance, a seismic wave that replicates seismic wave sources usedto examine a reservoir formation) and transmit such acoustic wave energy239 to the core holder 202 and thus to the core sample 212. In someaspects, such indirect acoustic wave energy transmitted by the acousticnoise source 238 may help evaluate a change in oil recovery due toseismic energy during testing of the core sample 212.

As shown in this example, one or more inflatable balloons 236 may bepositioned at ends of the core holder 202, such as at interfaces betweenthe core holder 202 and the rods 230. In this example, there may be fourinflatable balloons 236 positioned at four corner interfaces of the coreholder 202 and the rods 230 (as there may be four rods 230 used in thesystem 200). Each of the inflatable balloons 236 may be independentlyinflatable with an airflow source (not shown) by the control system 999to tilt the core holder 202 about any of the axes in the x-y-zcoordinate system 244, either alone or in combination. For instance, asshown in FIG. 2B, one of the inflatable balloons 236 (on the right sideof the figure) is more inflated than another of the balloons 236 (on theleft side of the figure), thereby causing the core holder 202 to tiltabout the x-axis.

In some aspects, operation of any combination of the inflatable balloons236, the rotational plate 226, the mechanical vibrator 224, the acousticvibrator 235, the rods230/balloons 234, and the acoustic noise source238 may occur simultaneously or sequentially. Thus, a single, two,three, or more of these described features of the core flooding system200 may be operated in any combination together or in series. Further,in some aspects, changes in temperature, pressure, or both, within theinner volume 206 (and thus the core sample 212) may be made in parallelwith or sequentially with these described features of the core floodingsystem 200. Still further, changes in properties of the fluid 220 (forexample, composition, pressure, temperature, and otherwise) may be madein parallel with or sequentially with operation of these describedfeatures of the core flooding system 200, as well as in parallel with orsequentially with other conventional testing parameters (for example,temperature or pressure).

As shown in this example, the core flooding system 200 includes one ormore fluid sensors 240 (in this case, one on each inlet 214 a-214 c andanother on the outlet 216), as well as other sensors 241 and 242. Insome aspects, each sensor shown in FIGS. 2A-2B may represent one ormultiple sensors. Each sensor shown in FIGS. 2A-2B may also be an analogor digital sensor. In some aspects, the illustrated sensors 240, 241,and 242 may be fiber optic conductors.

As shown in this example, one or more sensors 242 may be positionedwithin the internal volume 206 (but external to the sleeve 210).Further, in this example implementation, one or more sensors 241 may bepositioned between the core sample 212 and the sleeve 210.Alternatively, sensors may be placed external to (for example, incontact with an exterior surface of) the housing 204.

The example implementation of the core flooding system 200 includes acontrol system 999. In some implementations, the control system 999 is amicroprocessor-based control system that includes one or more hardwareprocessors, one or more memory modules communicably coupled to thehardware processor(s), and instructions and data encoded on the one ormore memory modules. The hardware processor(s) are operable to executethe instructions to perform operations, including operations describedin the present disclosure. As shown in this example (for instance, bythe bi-directional arrows 247), the control system 999 may becommunicably coupled (wired or wirelessly) to, for instance, theinflatable balloons 236 (for example, an airflow source fluidly coupledto the balloons 236), the rotational plate 226, the mechanical vibrator224, the acoustic vibrator 235, the rods230/balloons 234 (for example,an airflow source fluidly coupled to the balloons 236), and the acousticnoise source 238. In some aspects, the control system 999 may receivedata from the such components, as well as the sensors 240, 241, and 242.The control system 999 may also provide commands (pre-programmed orotherwise) to the inflatable balloons 236 (for example, an airflowsource fluidly coupled to the balloons 236), the rotational plate 226,the mechanical vibrator 224, the acoustic vibrator 235, therods230/balloons 234 (for example, an airflow source fluidly coupled tothe balloons 236), and the acoustic noise source 238.

For example, in an example operation, the control system 999 may commandone or more of the mechanical vibrator 224, the acoustic vibrator 235,the rods 230/balloons 234 (for example, an airflow source fluidlycoupled to the balloons 236), and the acoustic noise source 238togenerate and transmit the vibration and/or acoustic wave energy 228,239, or other energy to the core holder 202 (and thus the core sample212). For example, two or more of such components can be operated incombination depending on, for example, a type of the core sample 212, aswell as wave signature and intensity derived from the relevant fieldfrom which the core sample 212 was collected. Thus, in some aspects, thecore flooding system 200 may operate to downscale field scale waves to alab-level approach and create a comparable range of such waves. In someaspects, waves signatures may also depend on the source of waves in thefield (for example, tectonic movement, earthquake, from seismic truck,from injection or hydraulic fracturing) to be emulated by the coreflooding system 200. Also, depending on a clarity of the wave signatureand ability of differentiating them from the field, multiple energywaves can be combined during operation of the core flooding system 200.

The control system 999 may also command at least one of the inflatableballoons 236 (for example, an airflow source fluidly coupled to theballoons 236) or the rotational plate 226, either simultaneous with orsequentially with the operation of the components that generatevibration and/or acoustic wave energy. The control system 999 may alsocommand one or more valves fluidly coupled to the inlets 214 a-214 c andthe outlet 216 to facilitate circulation of the fluids 220 a-220 c intothe inner volume 206 of the core holder 202 (and thus to the core sample212), either simultaneous with or sequentially with the operation of therotation and vibration/acoustic energy components. Further, the controlsystem 999 may operate to adjust a temperature or pressure within theinner volume 206.

The sensors 240, 241, and/or 242 may measure one or more parametersassociated with the core sample 212, such as temperatures, confiningstresses (for example, to mimic reservoir confining stress whensubjected to different acoustic or seismic energy waves), pressures,fluid content, directional flow (for example, velocity, pathways, orboth) of one or more phases of a multiphase fluid, and other parameters.In some aspects, for instance, movement (for instance, rotation,tilting, vibration) of the core holder 202 in different directions canaffect the evaluation of directional permeability, vertical permeability(such as in tilted reservoirs) and can evaluate gravity drainage effectson remaining oil saturation (SOR) and additional hydrocarbon recovery ina reservoir.

Based on such measurements, the control system 999 may determine one ormore properties of the core sample 212, and also a reservoir formationfrom which the core sample 212, was taken. Such properties include, forexample, porosity, grain density, directional permeability, and otherproperties. In some aspects, results of the determination of the one ormore properties may be presented to a user or operator of the coreflooding system 100 through a graphical user interface (GUI) of thecontrol system 999.

In some aspects, in some aspects, X-ray attenuation can be attached tothe core holder 202 or on the core sample 212 to monitor the in situsaturation of each fluid 220 a-220 c across the core sample 212. Sensors241, therefore, can measure the attenuation in order for a determinationof preferred paths for each fluid 220 a-220 c. As another example ofdetermining fluid pathways, as the core holder 212 is tilted or rotated,gravity segregation of the fluids 220 a-220 c may occur, and the heavierfluid(s) will follow a path through the core sample 212 lower (forexample, closer to ground) than lighter fluid(s). Deviations from suchpathways by the fluids 220 a-220 c may indicate the existence ofheterogeneity.

In still further aspects, sensors fluidly coupled to the inlets 214a-214 c may determine compositions, flow rates, temperatures, andpressures of the fluids 220 a-220 c. Such sensors may provide an initialset of data for the input fluids 220 a-220 c that can then be compared(for example, by the control system 999) to measurements (compositions,flow rates, temperatures, and pressures) of the fluids 220 a-220 c asthey mix and flow through the core sample 212 by the sensors 241). Suchcomparisons may be used to determine (for example, by the control system999) fluid pathway information, as well as properties of the core sample212 such as permeability, porosity, and others.

FIG. 3 is a flowchart that describes an example method 300 performedwith a core flooding system according to the present disclosure. In someaspects, method 300 may be performed with either of the core floodingsystem 100 or the core flooding system 200 shown in this disclosure.Method 300 may begin at step 302, which includes positioning asubterranean formation core sample in an inner volume of a housing of acore holder. For example, a core sample may be inserted into a volume ofa core holder of a core flooding system and, in some aspects, into asleeve that is positioned in the volume. The volume may be sealed to anambient environment but with at least one fluid inlet and at least onefluid outlet that fluidly couple the volume to a source of one or morefluids (such as oil, gas, water). The core flooding system can includesensors (such as fiber optic sensors) positioned in various locations,such as in the inlet and/or outlet, within the volume, in contact withthe core holder, or between the sleeve and the core sample, as someexamples.

Method 300 may continue at step 304, which includes circulating a fluidthrough the inner volume of the core holder to contact the core sample.For example, a mixture of oil, gas and water, or even separate streamsof oil, gas, and water, can be circulated into the volume through theinlet, and circulated out of the volume (for example, in a continuous orsemi-continuous stream) through the outlet. One or more valves may beoperated to circulate the fluid through the volume to contact and, insome cases, saturate, the core sample. In some aspects, one or morepumps may also be operated to circulate the fluid through the volume tocontact and, in some cases, saturate, the core sample.

Method 300 may continue at step 306, which includes transmitting atleast one of an acoustic wave energy or a vibration energy to the coreholder. For example, the core flooding system may include one ormultiple sub-assemblies operable to generate and transmit one or both ofvibration energy or acoustic wave energy. In some aspects, one or moresub-assemblies may be in direct contact with the core sample andgenerate and transmit one or both of vibration energy or acoustic waveenergy directly to the core sample. In some aspects, one or moresub-assemblies may be in indirect contact with the core sample (forexample, in contact with a component of the core flooding system that isin contact with the core sample) and generate and transmit one or bothof vibration energy or acoustic wave energy indirectly to the coresample. In some aspects, one or more sub-assemblies may be remote thecore sample and generate and transmit one or both of vibration energy oracoustic wave energy to the core sample through an ambient environment.

Method 300 may continue at step 308, which includes rotating the coreholder about at least one axis. For example, the core flooding systemmay include one or more rotation sub-assemblies that operate to tilt orrotate the core holder, and thus core sample, about one or more axes ofa three-dimensional coordinate system. For example, a core sample, oftenbeing cylindrical in shape, may be rotated about a centerline radialaxis. The core sample may also be rotated or tilted about one or moreaxes that extend through a diameter of the core sample (and areorthogonal to the radial axis). In some aspects, steps 304 through 308may be performed in a different order or may be performed (and continueto be performed) simultaneously). In some aspects, step 304 or step 308may not be part of method 300.

Method 300 may continue at step 310, which includes measuring at leastone parameter of the core sample with at least one sensor. For example,as the core sample is receiving or has received the circulated fluid,and as the core sample is receiving the transmitted vibration oracoustic wave energy, and as the core sample is being rotated or tilted,sensors of the core flooding system may take one or more measurements.Such measurements may be, for example, fluid composition, fluidpressure, fluid temperature, core sample temperature, core samplepressure, gamma or X-ray attenuation, contact angle, interfacialtension, and other parameters. Such measurements may be provided by thesensor(s) to a control system that is part of or coupled to the coreflooding system.

Method 300 may continue at step 312, which includes based on the atleast one measured parameter, determining at least one property of thecore sample. For example, the control system may determine properties ofthe core sample such as fluid flow pathways (and other properties, suchas velocity, of the fluid(s) flowing through the core sample),permeability, porosity, as well as others. In some aspects, the measurevalues, as well as the determined property (or properties) may bepresented to a user on a GUI of the control system. Such propertydeterminations may allow for further determinations. For example,decisions and designs of future oil recovery (EOR) processes,injectivity, and water shut off jobs may be better informed due to thedeterminations made in step 312. As another example, the core floodingsystem may better assess certain parameters (such as interfacial tensionand contact angle) that are helpful for hydrocarbon reserve evaluationand fluids distribution in oil and gas reservoirs as compared toconventional techniques based on the determinations made in step 312.Thus, the determinations made in step 312 may allow for greater time andresource efficiencies associated with well completions by providing moreaccurate reservoir information based on the tested core sample.

FIG. 4 is a schematic illustration of an example controller 400 (orcontrol system) for controlling operations of a core flooding systemaccording to the present disclosure. For example, the controller 400 mayinclude or be part of the control system 999 shown in FIGS. 1 and 2A-2B.The controller 400 is intended to include various forms of digitalcomputers, such as printed circuit boards (PCB), processors, digitalcircuitry, or otherwise that is part of a core flooding system.Additionally the system can include portable storage media, such as,Universal Serial Bus (USB) flash drives. For example, the USB flashdrives may store operating systems and other applications. The USB flashdrives can include input/output components, such as a wirelesstransmitter or USB connector that may be inserted into a USB port ofanother computing device.

The controller 400 includes a processor 410, a memory 420, a storagedevice 430, and an input/output device 440. Each of the components 410,420, 430, and 440 are interconnected using a system bus 450. Theprocessor 410 is capable of processing instructions for execution withinthe controller 400. The processor may be designed using any of a numberof architectures. For example, the processor 410 may be a CISC (ComplexInstruction Set Computers) processor, a RISC (Reduced Instruction SetComputer) processor, or a MISC (Minimal Instruction Set Computer)processor.

In one implementation, the processor 410 is a single-threaded processor.In another implementation, the processor 410 is a multi-threadedprocessor. The processor 410 is capable of processing instructionsstored in the memory 420 or on the storage device 430 to displaygraphical information for a user interface on the input/output device440.

The memory 420 stores information within the controller 400. In oneimplementation, the memory 420 is a computer-readable medium. In oneimplementation, the memory 420 is a volatile memory unit. In anotherimplementation, the memory 420 is a non-volatile memory unit.

The storage device 430 is capable of providing mass storage for thecontroller 400. In one implementation, the storage device 430 is acomputer-readable medium. In various different implementations, thestorage device 430 may be a floppy disk device, a hard disk device, anoptical disk device, or a tape device.

The input/output device 440 provides input/output operations for thecontroller 400. In one implementation, the input/output device 440includes a keyboard and/or pointing device. In another implementation,the input/output device 440 includes a display unit for displayinggraphical user interfaces.

The features described can be implemented in digital electroniccircuitry, or in computer hardware, firmware, software, or incombinations of them. The apparatus can be implemented in a computerprogram product tangibly embodied in an information carrier, forexample, in a machine-readable storage device for execution by aprogrammable processor; and method steps can be performed by aprogrammable processor executing a program of instructions to performfunctions of the described implementations by operating on input dataand generating output. The described features can be implementedadvantageously in one or more computer programs that are executable on aprogrammable system including at least one programmable processorcoupled to receive data and instructions from, and to transmit data andinstructions to, a data storage system, at least one input device, andat least one output device. A computer program is a set of instructionsthat can be used, directly or indirectly, in a computer to perform acertain activity or bring about a certain result. A computer program canbe written in any form of programming language, including compiled orinterpreted languages, and it can be deployed in any form, including asa stand-alone program or as a module, component, subroutine, or otherunit suitable for use in a computing environment.

Suitable processors for the execution of a program of instructionsinclude, by way of example, both general and special purposemicroprocessors, and the sole processor or one of multiple processors ofany kind of computer. Generally, a processor will receive instructionsand data from a read-only memory or a random access memory or both. Theessential elements of a computer are a processor for executinginstructions and one or more memories for storing instructions and data.Generally, a computer will also include, or be operatively coupled tocommunicate with, one or more mass storage devices for storing datafiles; such devices include magnetic disks, such as internal hard disksand removable disks; magneto-optical disks; and optical disks. Storagedevices suitable for tangibly embodying computer program instructionsand data include all forms of non-volatile memory, including by way ofexample semiconductor memory devices, such as EPROM, EEPROM, and flashmemory devices; magnetic disks such as internal hard disks and removabledisks; magneto-optical disks; and CD-ROM and DVD-ROM disks. Theprocessor and the memory can be supplemented by, or incorporated in,ASICs (application-specific integrated circuits).

To provide for interaction with a user, the features can be implementedon a computer having a display device such as a CRT (cathode ray tube)or LCD (liquid crystal display) monitor for displaying information tothe user and a keyboard and a pointing device such as a mouse or atrackball by which the user can provide input to the computer.Additionally, such activities can be implemented via touchscreenflat-panel displays and other appropriate mechanisms.

The features can be implemented in a control system that includes aback-end component, such as a data server, or that includes a middlewarecomponent, such as an application server or an Internet server, or thatincludes a front-end component, such as a client computer having agraphical user interface or an Internet browser, or any combination ofthem. The components of the system can be connected by any form ormedium of digital data communication such as a communication network.Examples of communication networks include a local area network (“LAN”),a wide area network (“WAN”), peer-to-peer networks (having ad-hoc orstatic members), grid computing infrastructures, and the Internet.

While this specification contains many specific implementation details,these should not be construed as limitations on the scope of anyinventions or of what may be claimed, but rather as descriptions offeatures specific to particular implementations of particularinventions. Certain features that are described in this specification inthe context of separate implementations can also be implemented incombination in a single implementation. Conversely, various featuresthat are described in the context of a single implementation can also beimplemented in multiple implementations separately or in any suitablesubcombination. Moreover, although features may be described above asacting in certain combinations and even initially claimed as such, oneor more features from a claimed combination can in some cases be excisedfrom the combination, and the claimed combination may be directed to asubcombination or variation of a subcombination.

Similarly, while operations are depicted in the drawings in a particularorder, this should not be understood as requiring that such operationsbe performed in the particular order shown or in sequential order, orthat all illustrated operations be performed, to achieve desirableresults. In certain circumstances, multitasking and parallel processingmay be advantageous. Moreover, the separation of various systemcomponents in the implementations described above should not beunderstood as requiring such separation in all implementations, and itshould be understood that the described program components and systemscan generally be integrated together in a single software product orpackaged into multiple software products.

A number of implementations have been described. Nevertheless, it willbe understood that various modifications may be made without departingfrom the spirit and scope of the disclosure. For example, exampleoperations, methods, or processes described herein may include moresteps or fewer steps than those described. Further, the steps in suchexample operations, methods, or processes may be performed in differentsuccessions than that described or illustrated in the figures.Accordingly, other implementations are within the scope of the followingclaims.

What is claimed is:
 1. A core flooding system, comprising: a core holderthat comprises a housing that defines an inner volume sized to enclose acore sample of a subterranean formation, the core holder furthercomprising a fluid inlet and a fluid outlet; at least one sensor coupledto the core holder or positioned in the inner volume of the core holder;an acoustic vibrating assembly coupled to the core holder; and a controlsystem communicably coupled to the at least one sensor and the acousticvibrating assembly and configured to perform operations comprising:operating the acoustic vibrating assembly to transmit at least one of anacoustic wave energy or a vibration energy to the core holder; duringthe transmission of the at least one of the acoustic wave energy or thevibration energy to the core holder; measuring at least one parameter ofthe core sample with the at least one sensor; and based on the at leastone measured parameter, determining at least one property of the coresample.
 2. The core flooding system of claim 1, wherein the acousticvibrating assembly comprises a mechanical vibrator mounted on aplatform, the mechanical vibrator coupled to the core holder.
 3. Thecore flooding system of claim 2, wherein the platform comprises at leastone rotating plate to which the core holder is mounted.
 4. The coreflooding system of claim 3, wherein the control system is configured toperform operations further comprising operating the at least onerotating plate to rotate the core holder about an axis.
 5. The coreflooding system of claim 4, wherein the axis comprises a first axis, thecontrol system configured to perform operations further comprisingoperating the at least one rotating plate to rotate the core holderabout a second axis.
 6. The core flooding system of claim 5, whereinoperating the at least one rotating plate to rotate the core holderabout the second axis is performed simultaneously with operating the atleast one rotating plate to rotate the core holder about the first axis.7. The core flooding system of claim 2, further comprising at least onespring mounted to the mechanical vibrator.
 8. The core flooding systemof claim 1, wherein the acoustic vibrating assembly comprises: at leastone perforated rod that comprises an airflow path; and at least oneballoon fluidly coupled to the airflow path through the perforated rod.9. The core flooding system of claim 8, wherein the control system isconfigured to perform operations further comprising flowing a gasthrough the airflow path to inflate the at least one balloon to inducethe vibration energy through the core holder.
 10. The core floodingsystem of claim 1, further comprising a sleeve mountable within theinner volume and sized to hold the core sample, the acoustic vibratingassembly comprising a vibrator mounted within the sleeve to impart theat least one of the acoustic wave energy or the vibration energy to thecore sample.
 11. The core flooding system of claim 1, wherein theacoustic vibrating assembly comprises a noise source positionable apartfrom the core holder, the control system configured to performoperations further comprising operating the noise source to generate theacoustic wave energy.
 12. The core flooding system of claim 1, furthercomprising at least one valve fluidly coupled to at least one of thefluid inlet or the fluid outlet, the control system configured toperform operations further comprising operating the at least one valveto flow a fluid through the inner volume of the core holder.
 13. Thecore flooding system of claim 12, wherein the operation of operating theat least one valve to flow the fluid through the inner volume of thecore holder occurs simultaneously with operating the acoustic vibratingassembly to transmit at least one of the acoustic wave energy or thevibration energy to the core holder.
 14. A method for testing a coresample, comprising: positioning a subterranean formation core sample inan inner volume of a core holder, the core holder comprising a housingthat defines the inner volume, a fluid inlet, and a fluid outlet;transmitting at least one of an acoustic wave energy or a vibrationenergy to the core holder; during the transmission of the at least oneof the acoustic wave energy or the vibration energy to the core holder;measuring at least one parameter of the core sample with at least onesensor coupled to the core holder or positioned in the inner volume ofthe core holder; and based on the at least one measured parameter,determining at least one property of the core sample.
 15. The method ofclaim 14, wherein transmitting at least one of the acoustic wave energyor the vibration energy to the core holder comprises operating amechanical vibrator coupled to the core holder and mounted on aplatform.
 16. The method of claim 15, further comprising rotating thecore holder about an axis with at least one rotating plate to which thecore holder is mounted.
 17. The method of claim 16, wherein the axiscomprises a first axis, the method further comprising rotating the coreholder about a second axis with the at least one rotating plate.
 18. Themethod of claim 17, wherein rotating the core holder about the first andsecond axes occurs simultaneously.
 19. The method of claim 14, whereintransmitting at least one of the acoustic wave energy or the vibrationenergy to the core holder comprises: flowing a fluid through an airflowpath of at least one perforated rod coupled to the core holder;inflating at least one balloon fluidly coupled to the airflow paththrough the perforated rod; and based on inflating the at least oneballoon, transmitting at least one of the acoustic wave energy or thevibration energy to the core holder.
 20. The method of claim 14, furthercomprising, while transmitting at least one of the acoustic wave energyor the vibration energy to the core holder: inflating at least oneballoon mounted to the core holder; and based on inflating the at leastone balloon, tilting the core holder.
 21. The method of claim 14,wherein transmitting at least one of the acoustic wave energy or thevibration energy to the core holder comprises vibrating the core samplewith a vibrator mounted to or within a sleeve that holds the core sampleto impart the at least one of the acoustic wave energy or the vibrationenergy to the core sample.
 22. The method of claim 14, whereintransmitting at least one of the acoustic wave energy or the vibrationenergy to the core holder comprises generating the acoustic wave energywith a noise source positioned apart from the core holder.
 23. Themethod of claim 14, further comprising: modulating at least one valvefluidly coupled to at least one of the fluid inlet or the fluid outlet;and circulating a fluid through the inner volume of the core holder tocontact the core sample.
 24. A core sample test apparatus, comprising: ahousing sized to receive a core sample that comprises a portion of ahydrocarbon reservoir formation; means for generating at least one of anacoustic wave energy or a vibration energy to the core holder; at leastone sensor positioned to detect a change in at least one parameter ofthe core sample during operation of the means for generating the atleast one of the acoustic wave energy or the vibration energy; and acontrol system communicably coupled to the at least one sensor andconfigured to receive the change in the at least one parameter of thecore sample and determine at least one property of the hydrocarbonreservoir formation.
 25. The core sample test apparatus of claim 24,wherein the control system is operably coupled to the means forgenerating.
 26. The core sample test apparatus of claim 24, furthercomprising means for rotating the core sample.
 27. The core sample testapparatus of claim 26, wherein the control system is operably coupled tothe means for rotating.
 28. The core sample test apparatus of claim 24,wherein the at least one parameter of the core sample comprises at leastone of: a flow rate of a fluid through the core sample; an interfacialtension; a contact angle between a fluid and the core sample; a fluidpath of water or brine through the core sample; or a fluid path of ahydrocarbon through the core sample.
 29. The core sample test apparatusof claim 24, wherein the at least one property of the hydrocarbonreservoir formation: a permeability of the hydrocarbon reservoirformation; a brine permeability of the hydrocarbon reservoir formation;or a porosity of the hydrocarbon reservoir formation.
 30. The coresample test apparatus of claim 24, wherein the sensor comprises a fiberoptic conductor mounted within a sleeve configured to hold the coresample in the housing.